EP2082178B1 - Procédé et dispositif pour réfrigérer un courant d'hydrocarbures - Google Patents

Procédé et dispositif pour réfrigérer un courant d'hydrocarbures Download PDF

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Publication number
EP2082178B1
EP2082178B1 EP07822489.6A EP07822489A EP2082178B1 EP 2082178 B1 EP2082178 B1 EP 2082178B1 EP 07822489 A EP07822489 A EP 07822489A EP 2082178 B1 EP2082178 B1 EP 2082178B1
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Prior art keywords
stream
streams
cooling
treated
stage
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EP07822489.6A
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German (de)
English (en)
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EP2082178A2 (fr
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Willem Dam
Casper Krijno Groothuis
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Shell Internationale Research Maatschappij BV
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Shell Internationale Research Maatschappij BV
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Priority to CY181101027T priority patent/CY1120954T1/el
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    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/02—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen ; Details and kind of the refrigeration system used; Integration with other units or processes; Controlling aspects of the process
    • F25J1/0243—Start-up or control of the process; Details of the apparatus used; Details of the refrigerant compression system used
    • F25J1/0257—Construction and layout of liquefaction equipments, e.g. valves, machines
    • F25J1/0269—Arrangement of liquefaction units or equipments fulfilling the same process step, e.g. multiple "trains" concept
    • F25J1/0271—Inter-connecting multiple cold equipments within or downstream of the cold box
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/0002—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the fluid to be liquefied
    • F25J1/0022—Hydrocarbons, e.g. natural gas
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/02—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen ; Details and kind of the refrigeration system used; Integration with other units or processes; Controlling aspects of the process
    • F25J1/0243—Start-up or control of the process; Details of the apparatus used; Details of the refrigerant compression system used
    • F25J1/0257—Construction and layout of liquefaction equipments, e.g. valves, machines
    • F25J1/0269—Arrangement of liquefaction units or equipments fulfilling the same process step, e.g. multiple "trains" concept
    • F25J1/027—Inter-connecting multiple hot equipments upstream of the cold box
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2220/00—Processes or apparatus involving steps for the removal of impurities
    • F25J2220/60—Separating impurities from natural gas, e.g. mercury, cyclic hydrocarbons
    • F25J2220/64—Separating heavy hydrocarbons, e.g. NGL, LPG, C4+ hydrocarbons or heavy condensates in general
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2220/00—Processes or apparatus involving steps for the removal of impurities
    • F25J2220/60—Separating impurities from natural gas, e.g. mercury, cyclic hydrocarbons
    • F25J2220/66—Separating acid gases, e.g. CO2, SO2, H2S or RSH
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2290/00—Other details not covered by groups F25J2200/00 - F25J2280/00
    • F25J2290/10—Mathematical formulae, modeling, plot or curves; Design methods

Definitions

  • the present invention relates to a method and apparatus for cooling, optionally also liquefying, a hydrocarbon stream such as natural gas according to the preamble of claims 1 and 10 respectively.
  • a hydrocarbon stream such as natural gas according to the preamble of claims 1 and 10 respectively.
  • Such a method respectively apparatus is known from WO 2006/087331 A1 .
  • Several methods of liquefying a natural gas stream thereby obtaining liquefied natural gas (LNG) are known. It is desirable to liquefy a natural gas stream for a number of reasons.
  • natural gas can be stored and transported over long distances more readily as a liquid than in gaseous form, because it occupies a smaller volume and does not need to be stored at a high pressure.
  • natural gas comprising predominantly methane
  • the purified gas is processed through a plurality of cooling stages using heat exchangers to progressively reduce its temperature until liquefaction is achieved.
  • the liquid natural gas is then further cooled and expanded to final atmospheric pressure suitable for storage and transportation.
  • the flashed vapour from each expansion stage can be used as a source of plant fuel gas.
  • natural gas usually includes some heavier hydrocarbons and impurities, including but not limited to carbon dioxide, sulphur, hydrogen sulphide and other sulphur compounds, nitrogen, helium, water and other non-hydrocarbon acid gases, ethane, propane, butanes, C 5 + hydrocarbons and aromatic hydrocarbons.
  • these and any other common or known heavier hydrocarbons and impurities either prevent or hinder the usual known methods of liquefying the methane, especially the most efficient methods of liquefying methane.
  • Most if not all known or proposed methods of liquefying hydrocarbons, especially liquefying natural gas are based on reducing as far as possible the levels of at least most of the heavier hydrocarbons and impurities prior to the liquefying process.
  • the capacity of a liquefaction plant is usually determined by the availability of the gas feed stream, and the market or expected markets for products provided by the plant.
  • extra capacity at a liquefaction plant has simply involved the complete replication of all of the units dealing with the gas feed stream, from its source to its storage. All such units are often termed a "train”.
  • train Some commonality of some units of a train or its support units such as refrigeration units have been suggested, but no flexibility in the pre-treatment of the gas has been suggested.
  • LNG liquefying natural gas
  • WO 2006/009646 A2 relates to a hydrocarbon fluid processing plant including a plurality of process unit module types, including first and second process unit module types having modules intended to be sized at their respective substantially maximum processing efficiency.
  • WO 2006/009646 A2 shows a number of plant arrangements but a problem with these arrangements is that there are always complete 'trains' for treating and liquefying the hydrocarbon fluids, without flexibility therebetween.
  • WO 2006/087331 A1 discloses a plant for liquefying natural gas.
  • the plant comprises a natural gas pre-cooling heat exchanger train, a distributor, two main cryogenic systems, and two natural gas liquids extraction units.
  • the present invention provides a method of cooling a hydrocarbon stream such as natural gas according to claim 1.
  • the present invention provides an apparatus for cooling a hydrocarbon stream such as natural gas according to claim 10.
  • the method and apparatus described herein comprises a gas treatment stage, an NGL extraction stage and a cooling stage.
  • the gas treatment stage comprises one or more parallel gas treatment units; the NGL extraction stage comprises more than one parallel NGL extraction units; and the cooling stage comprises one or more parallel cooling systems.
  • the number of gas treatment units will hereinafter be represented by the letter X; the number of NGL extraction units as Y, and the number of cooling systems as Z.
  • parallel means arranged or operated in parallel with respect to other units or systems of same type when more than one of that type of unit or system is provided.
  • an asymmetric arrangement between the number of gas treatment units, the number of NGL extraction units, and the number of cooling systems is provided.
  • An asymmetric configuration offers benefits in terms of overall plant availability and matching of individual unit equipment sized design capacity constraints.
  • the number of NLG extraction units is higher than the number of cooling systems (i.e. Y > Z). This advantageous choice is based on an insight that limits in vapour expander size are typically more restrictive than the size of a cooling system in terms of production capacity.
  • NGL extraction units are typically based on an expander. Thus, production capacity can be increased by operating in parallel more expander-based extraction units than there are cooling systems.
  • providing Y > Z offers the possibility of providing an excess of NGL extraction capacity relative to cooling capacity. Generating excess NGL-extracted gas may be useful to provide domestic gas from a hydrocarbon stream cooling site.
  • both X and Y are unequal to Z, whereby at least Y is greater than one.
  • the asymmetry provided herein also allows the energy requirements of the liquefaction facility or plant to be more balanced.
  • An asymmetric configuration also offers the user of a plant options and flexibility should a gas treatment unit or an NGL extraction unit be off-line, i.e. non-operational, either accidentally or deliberately for maintenance, etc.. Whilst there may be some reduction in plant output or in one or more stream flows, overall, the plant can remain operational through the use of other gas treatment units and NGL extraction units.
  • the level or levels of certain impurities generally not being hydrocarbons can be reduced.
  • Two common impurities are carbon dioxide and sulphur (and sulphur-based compounds), usually present with water in the form of 'acid gas'.
  • Many processes for the removal of acid gas from a feed stream are known to those skilled in the art.
  • One common method is the use of an aqueous amine solution, often used in an extraction column termed a 'scrubber'.
  • the aqueous amine may be one or more of known materials including for example DGA, DEA, MDEA, MEA and SULFINOLTM (Shell), and combinations thereof.
  • the gas treatment stage comprises one or more parallel gas treatment units.
  • gas treatment unit is meant a unit comprising one or more solvent-fed extraction columns which remove acid gas from the hydrocarbon stream under elevated pressure (relative to solvent regeneration pressure) to produce enriched solvent and a treated hydrocarbon stream.
  • the enriched solvent is then passed within the gas treatment unit to one or more pressure let-down devices and then to one or more heaters or regeneration columns which separate the solvent from the acid gas and recycle at least a portion of the solvent to the one or more extraction columns.
  • the extraction columns and heaters or regeneration columns of the gas treatment unit represent equipment which is dedicated to a single gas treatment unit such that they are not shared with any other gas treatment units.
  • the NGL extraction stage comprises more than one parallel NGL extraction units.
  • NGL extraction unit is meant a unit comprising one or more knock-out drums from which the hydrocarbon stream is passed, via an expansion step, to one or more NGL separators which produce an NGL stream or streams, which each comprise, for instance, less than 5 mole % methane.
  • the knock-out drums and NGL separators of the NGL extraction unit represent equipment which is dedicated to a single NGL extraction unit such that they are not shared with any other NGL extraction units. However, subsequent separation of the NGL stream into individual hydrocarbon streams, often referred to as fractionation, can be carried out in a facility shared between NGL extraction units.
  • NGL extraction units as such are known to those skilled in the art. Generally, they are designed to reduce the level or levels of hydrocarbon compounds other than methane in a feed stream.
  • One common NGL extraction unit includes a separator or separation vessel, able to provide a gaseous stream that is methane-enriched, and one or more other streams. Such other stream or streams usually but not always include separate or combined streams of heavier hydrocarbons.
  • the methane-enriched stream may be passed through the cooling stage.
  • an NGL extraction unit provides a single heavier hydrocarbon rich stream, which is subsequently used either per se, or is further divided into particular heavier hydrocarbon rich streams in a separate location or unit.
  • the division of a heavier hydrocarbon rich stream can be carried out by one or more separators known in the art, such as a fractionator.
  • a fractionator using one or more columns could provide individual streams of certain heavier hydrocarbons.
  • each column could be designed to provide an individual hydrocarbon stream, such as an ethane-rich stream, a propane-rich stream, a butane-rich stream, and a C 5 + -rich stream, the latter sometimes also termed a 'light condensate stream'.
  • Propane, butane and C 5 + hydrocarbons are sometimes collectively termed "natural gas liquids" (NGL), and have known uses.
  • an NGL extraction unit can include a fractionator which integrally provides individual streams of certain heavier hydrocarbons such as those listed hereinbefore.
  • Cooling systems for the cooling stage are known in the art.
  • the cooling system may be a liquefying system.
  • Cooling systems and liquefying systems may be embodied in various ways, and generally involve one or more heat exchangers and refrigerant circuits.
  • the cooling stage comprises one or more parallel cooling systems.
  • cooling system is meant a liquefying system comprising one or more closed, independent refrigerant cycles.
  • a closed refrigerant cycle does not exchange refrigerant with another cooling cycle under normal operation.
  • the closed, independent refrigerant cycle or cycles are dedicated to a single cooling system such that they are not shared with any other cooling systems.
  • a liquefying system useable with the present invention may involve a number of separate serial cooling steps, and the or each cooling step may involve one or more heat exchangers, levels or sections.
  • One arrangement involves the cooling stage having a first cooling step for pre-cooling, followed by a second cooling step for main cryogenic cooling and liquefying.
  • a first or pre-cooling step may involve reducing the temperature of a feed stream to below -0 °C, for example in the range -10 °C to -30 °C.
  • a second or main cryogenic cooling step may involve cooling a feed stream to below -90 °C or below -100 °C, for example between -100 °C to -130 °C, which usually creates a hydrocarbon stream which is now liquefied, such as liquefied natural gas.
  • Each unit or system of the stages of the present invention may use the same or different parameters, such as flowrate, temperature, pressure, etc.
  • a unit or system may be taken off-line for maintenance without having to shut down the entire hydrocarbon cooling plant.
  • the number of streams for each of the stages is intended to be shared to match the number of units or systems in each stage. This may therefore require the division, sharing or combination of the feed stream or the stream or streams provided by the previous stage. Such division, sharing and/or combination may or may not involve the complete mixing of previous streams, or the complete separation of previous streams.
  • Any division, sharing and/or combination of the feed stream or stream or streams provided by a previous stage may be unequally distributed.
  • the distribution is equal, that is, there is equidistribution of the stream or streams amongst the lines to the units or systems to which the stream or streams are intended to be passed to.
  • any of the feed streams or any of the subsequent treated or cooled hydrocarbon stream or streams could be provided by any suitable divisor, for example a stream splitter.
  • any division or sharing creates two or more streams having the same composition and phases.
  • X can be 2
  • Y can be 3
  • Z can be 2.
  • the feed stream is shared or divided into two part-feed streams for the two gas treatment units in the gas treatment stage.
  • the two first treated streams provided thereby are then shared to provide three first treated streams, one for each of the NGL extraction units in the NGL extraction stage.
  • the change from two to three first treated streams may be through a common manifold, or may be by any other sharing arrangement not having a common union or junction of all streams.
  • the three second treated streams provided by the NGL extraction stage are then shared to create two second treated streams for the two cooling systems. This sharing of the second treated streams may be through a common manifold, or through any other arrangement not involving commonality or union of all the second treated streams.
  • the present invention may also be used to create a facility or plant where X is 2, Y is 2 and Z is 1. Should there be a wish or need to enlarge the capacity of the facility or plant, one or more further gas treatment units, NGL extraction units, and/or cooling systems, can be added, taking into account the design capacity of existing units, thereby avoiding the hitherto expedient of having to supply a complete and separated liquefaction 'train'.
  • the feed stream may be any suitable hydrocarbon-containing gas stream to be cooled, but is usually a natural gas stream obtained from natural gas or petroleum reservoirs.
  • the natural gas stream may also be obtained from another source, also including a synthetic source such as a Fischer-Tropsch process.
  • the natural gas stream is comprised substantially of methane.
  • the feed stream comprises at least 60 mol% methane, more preferably at least 80 mol% methane.
  • Figure 1 shows a block scheme of part of a liquefied natural gas plant 1. It shows an initial feed stream 10 containing natural gas.
  • the feed stream 10 is divided by a stream splitter 12 into two part-feed streams 20a, 20b.
  • the division of the feed stream 10 could be based on any ratio of mass and/or volume and/or flow rate.
  • the ratio may be based on the size or capacity of the subsequent parts, systems or units of the plant, or due to other considerations.
  • One example of the ratio is an equal division of the cooled stream mass.
  • the two part-feed streams 20a, 20b pass to a gas treatment stage 2 comprising two parallel gas treatment units 14a, 14b.
  • gas treatment units 14a, 14b are adapted to reduce impurities, including but not limited to acid gas, in the part feed-streams 20a, 20b, and so provide two first treated streams 30a, 30b respectively.
  • Operation of gas treatment units 14a, 14b such as scrubbers are well known in the art.
  • Figure 1 shows an exit stream 15a, 15b for carbon dioxide, sulphur and any sulphur-based compounds from each gas treatment unit 14a, 14b.
  • the first treated streams 30a, 30b are passed to an NGL extraction stage 4 which comprises two parallel NGL extraction units 16a, 16b.
  • the NGL extraction units 16a, 16b provide two second treated streams 40a, 40b, which streams are methane-enriched, and which are combined to provide a combined treated stream 50.
  • the second treated feed streams 40a, 40b can be combined using a combiner 18 known in the art.
  • the combiner may be any suitable arrangement, generally involving a union or junction or piping or conduits, optionally involving one or more valves.
  • the NGL extraction units 16a, 16b also provide two heavier hydrocarbon enriched streams 17a, 17b which pass to a common fractionator 24.
  • the enriched streams 17a, 17b may be combined prior to entry into the common fractionator 24 as shown in Figure 1 , or may be passed separately into the common fractionator 24.
  • the common fractionator 24 is designed to provide separate enriched streams of one or more hydrocarbons such as propane, butane and C 5 + hydrocarbons, and optionally also ethane. Such enriched streams are useful products for use in the liquefying plant 1 or outside the plant. Such enriched streams are shown collectively in Figure 1 as streams 26.
  • the fractionator 24 may be a single fractionation unit, or have one or more columns, wherein each column is usually dedicated to separating and providing a particular heavier hydrocarbon. Fractionation is well known in the art and the benefit and use of individual streams of propane, butane and C 5 + are also well known in the art.
  • any methane stream or methane-enriched stream provided by the fractionator 24 may be returned or recycled back into the path of the second treated streams 40a, 40b or the combined stream 50.
  • the combined treated stream 50 is then passed to a cooling stage 6.
  • the cooling stage 6 provides a cooled hydrocarbon stream 60.
  • the cooling of the combined treated stream 50 in the cooling stage 6 may involve any degree of cooling using any number of units, devices or systems or combinations thereof known in the art.
  • One example is the use of one or more heat exchangers.
  • cooling is effected by passing the combined treated stream 50 against one or more cooling or refrigerant streams and/or through one or more valves and/or separators, as known in the art.
  • the cooling stage 6 is adapted to liquefy the combined treated stream 50 so as to provide a liquefied hydrocarbon stream such as liquefied natural gas.
  • Liquefaction of the combined treated stream 50 can be carried out by passing it through a cooling system being a liquefying system 22 using one or more heat exchangers and cooling it against one or more refrigerants, either being dedicated refrigerants or other cooled streams.
  • the liquefying can involve one or more cooling and/or liquefying steps.
  • a liquefied natural gas stream having a temperature below -150 °C, more usually between -160 °C and -165 °C.
  • NGL extraction stage 4 and the cooling stage 6 one or more other units or features may be involved such as valves or further treatments, or to control of the path or flow of the streams thereinbetween.
  • Figure 1 shows a method of treating a hydrocarbon stream such as natural gas wherein X is 2, Y is 2, and Z is 1. There is therefore asymmetry between the number of gas treatment units, the number of NGL extraction units, and the number of cooling systems.
  • An asymmetric configuration, particularly where Y > Z as in the embodiment of Figure 1 offers benefits as explained hereinabove.
  • FIG. 2 shows a block scheme of part of a liquefied natural gas plant 1a according to a second embodiment of the present invention.
  • a feed stream 10 is divided by a divider 12 into three part-feed streams 20a, 20b and 20c, either equally or unequally as described above.
  • the three part-feed streams 20a, 20b, 20c pass into three respective and parallel gas treatment units 14a, 14b and 14c which comprise the gas treatment stage 2.
  • the action and effect of the gas treatment units 14a, 14b, 14c is similar to those described hereinbefore. They provide three first treated streams 30a, 30b, 30c, and three other streams 15a, 15b, 15c, being for example, sulphur, carbon dioxide, etc.
  • the three first treatment streams 30a,b,c pass into respective and parallel NGL extraction units 16a, 16b, 16c, whose action and effect is similar to those described hereinbefore.
  • the units 16a, 16b, 16c provide three second treated streams 40a, 40b, 40c which are then shared for the cooling stage 6, and three heavier hydrocarbon streams 17a, 17b, 17c, whose use and/or separation can be the same or similar to that described above in Figure 1 .
  • references herein to the second treated streams being "shared" include the second treated streams being able to provide one or more streams to a cooling stage, which cooling stage may comprise one or more cooling systems.
  • the one or more streams supplying the cooling system or systems may therefore comprise flow from two or more second treated streams, without involving flow from all of the second treated streams.
  • all the second treated streams collectively supply their flow to the or all of the cooling systems of the cooling stage.
  • the three second treated streams 40a, 40b, 40c provide, via linked piping or conduits at junctions 19a, 19b, combined treated streams 50a, 50b, which pass respectively into two cooling systems 22a, 22b which comprise the cooling stage 6.
  • the cooling systems 22a, 22b preferably liquefy the combined treated streams 50a, 50b to provide two liquefied hydrocarbon streams 52a, 52b, which can be combined to provide a combined liquefied hydrocarbon stream 60, such as liquefied natural gas.
  • Figure 2 shows a method of treating a hydrocarbon stream such as natural gas wherein X is 3, Y is 3, and Z is 2.
  • FIG. 3 shows a simplified block scheme of part of a liquefied natural gas plant 1b according to a third embodiment of the present invention.
  • a feed stream 10 passes into a single gas treatment unit 100 for the gas treatment stage 2.
  • the action and effect of the gas treatment unit 100 is similar to those described hereinbefore.
  • This provides a first treated stream 30d which is optionally passed through a separate or integral drying unit 101 to reduce its water content, and provide a drier treated stream 30e.
  • the drier treated stream 30e is then divided by a divider 32, preferably equally, into 3 part-streams 30f, 30g, 30h, which pass into three respective and parallel NGL extraction units 102a, 102b and 102c, whose action and effect is similar to those described hereinbefore, and which comprise the NGL extraction stage 4.
  • the units 102a, b, c provide three second treated streams 40a, 40b, 40c, which are then combined using a combiner 34 to provide a single combined stream 50.
  • the combined stream 50 is then divided by a divider 36 into two part-streams 50a, 50b, optionally unequally or equally, to pass into two cooling systems 103a, 103b, similar to those described above, and which comprise the cooling stage 6.
  • the cooling systems 103a,b are preferably adapted to liquefy the part-streams 50a, 50b, to provide two liquefied hydrocarbon streams 52a, 52b, which can then be combined by a combiner 38 to provide a combined liquefied hydrocarbon stream 60, such as liquefied natural gas.
  • the liquefied natural gas 60 can pass through an endflash unit 104 in a manner commonly known in the art, to provide a final liquefied product stream 70.
  • Figure 3 shows another embodiment of the present invention having a gas treatment stage with one gas treatment unit, an NGL extraction stage having three NGL extraction units, and a cooling stage comprising two parallel cooling systems, i.e. a method of treating a hydrocarbon stream such as natural gas wherein X is 1, Y is 3, and Z is 2.

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Claims (14)

  1. Procédé de refroidissement d'un flux d'hydrocarbures tel que du gaz naturel, le procédé comprenant au moins les étapes suivantes :
    (a) produire un flux d'alimentation (10) ;
    (b) faire passer le flux d'alimentation (10) à travers un étage de traitement de gaz (2) comprenant X unités de traitement de gaz (14a, 14b), X étant une ou plusieurs, les unités de traitement de gaz fonctionnant en parallèle dans le cas où X est supérieur à un, le flux d'alimentation (10) étant divisé en deux ou plus de deux flux d'alimentation partiels (20a, 20b) s'il y a plus d'une unité de traitement de gaz, pour produire un ou plusieurs premiers flux traités (30a, 30b) ;
    (c) faire passer le ou les premiers flux traités (30a, 30b) de l'étape (b) par un étage d'extraction de LGN (4) comprenant Y unités d'extraction de LGN (16a, 16b) parallèles, Y étant supérieur à un, le ou les premiers flux traités (30a, 30b) étant partagés pour correspondre au nombre d'unités d'extraction de LGN (16a, 16b), pour produire un ou plusieurs deuxièmes flux traités (40a, 40b) ; et
    (d) faire passer le ou les deuxièmes flux traités (40a, 40b) de l'étape (c) par un étage de refroidissement (6) comprenant un ou Z systèmes de refroidissement (22), Z étant un ou plusieurs, les systèmes de refroidissement fonctionnant en parallèle dans le cas où Z est supérieur à un, le ou les Z systèmes de refroidissement étant un ou plusieurs systèmes de liquéfaction comprenant un ou plusieurs cycles de réfrigérant indépendants fermés, le ou les deuxièmes flux traités (40a, 40b) étant partagés pour correspondre au nombre de systèmes de refroidissement (22), pour produire un ou des flux d'hydrocarbures refroidis ;
    caractérisé en ce que Y > Z.
  2. Procédé selon la revendication 1, dans lequel le flux d'alimentation (10) est divisé en deux flux d'alimentation partiels (20a, 20b), et X est 2 et Z est 1, et/ou dans lequel Y est 2 et Z est 1.
  3. Procédé selon la revendication 1, dans lequel le flux d'alimentation (10) est divisé en trois flux d'alimentation partiels (20a, 20b, 20c), et X est 3 et Z est 1 ou 2, et/ou dans lequel Y est 3 et Z est 1 ou 2.
  4. Procédé selon l'une ou plusieurs des revendications précédentes, dans lequel chaque unité d'extraction de LGN (16a, 16b) produit un deuxième flux traité (40a, 40b) et un ou plusieurs flux séparés (17a, 17b).
  5. Procédé selon la revendication 4, dans lequel le ou les flux séparés comprennent un ou plusieurs parmi un flux de propane, un flux de butane et un flux de C5+.
  6. Procédé selon la revendication 4, dans lequel le ou les flux séparés (17a, 17b) sont fractionnés pour produire un ou plusieurs flux fractionnés (26).
  7. Procédé selon la revendication 5, dans lequel le ou les flux fractionnés (26) comprennent un ou plusieurs parmi un flux de propane, un flux de butane et un flux de C5+.
  8. Procédé selon l'une ou plusieurs des revendications précédentes, dans lequel X est différent de Z.
  9. Procédé selon l'une ou plusieurs des revendications précédentes, dans lequel l'étape de refroidissement (d) liquéfie le ou les deuxièmes flux traités (40a, 40b) pour produire un ou des flux d'hydrocarbures liquéfiés (60, de préférence du gaz naturel liquéfié.
  10. Appareil permettant de refroidir un flux d'hydrocarbures tel que du gaz naturel, l'appareil comprenant au moins :
    (i) un étage de traitement de gaz (2) pour recevoir un flux d'alimentation (10), comprenant une ou X unités de traitement de gaz (14a, 14b), X étant un ou plusieurs, les unités de traitement de gaz étant agencées en parallèle dans le cas où X est supérieur à un, le flux d'alimentation (10) étant divisé s'il y a plus d'une unité de traitement de gaz ;
    (ii) un étage d'extraction de LGN (4) pour recevoir le ou les flux traités à partir de l'étage de traitement de gaz, comprenant Y unités d'extraction de LGN (16a, 16b) parallèles, Y étant supérieur à un ; et
    (iii) un étage de refroidissement (6) pour recevoir le ou les flux extraits de LGN à partir de l'étage d'extraction de LGN, comprenant un ou Z systèmes de refroidissement (22), Z étant un ou plusieurs, les systèmes de refroidissement étant agencés en parallèle dans le cas où Z est supérieur à un, le ou les Z systèmes de refroidissement étant un ou plusieurs systèmes de liquéfaction comprenant un ou plusieurs cycles de réfrigérant indépendants fermés, pour produire un ou des flux d'hydrocarbures traités ;
    caractérisé en ce que Y > Z.
  11. Appareil selon la revendication 10, dans lequel X est 2 et Z est 1, et/ou dans lequel Y est 2 et Z est 1.
  12. Appareil selon la revendication 10, dans lequel X est 3 et Z est 1 ou 2, et/ou dans lequel Y est 3 et Z est 1 ou 2.
  13. Appareil selon l'une ou plusieurs des revendications 10 à 12, comprenant en outre une colonne de fractionnement (24) pour fractionner tous les flux parmi un ou plusieurs flux séparés (17a, 17b) produits par les unités d'extraction de LGN.
  14. Appareil selon l'une ou plusieurs des revendications 10 à 13, dans lequel X est différent de Z.
EP07822489.6A 2006-11-14 2007-11-12 Procédé et dispositif pour réfrigérer un courant d'hydrocarbures Active EP2082178B1 (fr)

Priority Applications (2)

Application Number Priority Date Filing Date Title
EP07822489.6A EP2082178B1 (fr) 2006-11-14 2007-11-12 Procédé et dispositif pour réfrigérer un courant d'hydrocarbures
CY181101027T CY1120954T1 (el) 2006-11-14 2018-10-05 Μεθοδος και διαταξη για την ψυξη ενος ρευματος υδρογονανθρακων

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
EP06124012 2006-11-14
EP07822489.6A EP2082178B1 (fr) 2006-11-14 2007-11-12 Procédé et dispositif pour réfrigérer un courant d'hydrocarbures
PCT/EP2007/062202 WO2008058926A2 (fr) 2006-11-14 2007-11-12 Procédé et dispositif de refroidissement de flux d'hydrocarbures

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AU (1) AU2007321248B2 (fr)
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US20100319397A1 (en) * 2009-06-23 2010-12-23 Lee Ron C Cryogenic pre-condensing method and apparatus
AU2010311649B2 (en) 2009-10-27 2014-03-20 Shell Internationale Research Maatschappij B.V. Apparatus and method for cooling and liquefying a fluid
US9612050B2 (en) * 2012-01-12 2017-04-04 9052151 Canada Corporation Simplified LNG process
US20200033054A1 (en) * 2017-02-28 2020-01-30 Shell Oil Company Additional liquid natural gas plant and method of operating thereof

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US4435198A (en) * 1982-02-24 1984-03-06 Phillips Petroleum Company Separation of nitrogen from natural gas
FR2545589B1 (fr) * 1983-05-06 1985-08-30 Technip Cie Procede et appareil de refroidissement et liquefaction d'au moins un gaz a bas point d'ebullition, tel que par exemple du gaz naturel
US4541852A (en) * 1984-02-13 1985-09-17 Air Products And Chemicals, Inc. Deep flash LNG cycle
US4901533A (en) * 1986-03-21 1990-02-20 Linde Aktiengesellschaft Process and apparatus for the liquefaction of a natural gas stream utilizing a single mixed refrigerant
EP0723125B1 (fr) * 1994-12-09 2001-10-24 Kabushiki Kaisha Kobe Seiko Sho Procédé et installation de liquéfaction de gaz
TW366411B (en) * 1997-06-20 1999-08-11 Exxon Production Research Co Improved process for liquefaction of natural gas
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BR0306494A (pt) * 2002-09-30 2004-10-13 Bp Corp North America Inc Métodos para operar e para projetar de forma eficiente e econÈmica um processo de liquefação de gás de hidrocarbonetos leves para liquefação de quantidades selecionadas de gás de hidrocarbonetos leves
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WO2008058926A2 (fr) 2008-05-22
RU2464510C2 (ru) 2012-10-20
EP2082178A2 (fr) 2009-07-29
CY1120954T1 (el) 2019-12-11
AU2007321248A1 (en) 2008-05-22
RU2009122376A (ru) 2010-12-20
WO2008058926A3 (fr) 2009-03-12
DK2082178T3 (en) 2018-11-26
US20080134717A1 (en) 2008-06-12
AU2007321248B2 (en) 2010-09-02

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